Safety Valve By-Pass System for Cable-Deployed Electric Submersible Pump

ABSTRACT

In an embodiment, a work string for downhole use in a well comprises a safety valve comprising a sealable flow path; a first electrical connection disposed above the safety valve; a second electrical connection disposed below the safety valve; and a jumper electrically coupling the first electrical connection and the second electrical connection, wherein the jumper does not pass through the sealable flow path of the safety valve.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a filing under 35 U.S.C. 371 of International Application No. PCT/US2012/039670 filed May 25, 2012, entitled “Safety Valve-By-Pass System for Cable-Deployed Electric Submersible Pump,” which claims priority to U.S. Provisional Application Ser. No. 61/490,984 filed May 27, 2011, which is incorporated herein by reference as if reproduced in its entirety.

STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT

Not applicable.

REFERENCE TO A MICROFICHE APPENDIX

Not applicable.

BACKGROUND

Wellbores are sometimes drilled into subterranean formations containing hydrocarbons to allow for recovery of the hydrocarbons. During the drilling and production of a hydrocarbon bearing formation, various procedures may be performed that involve temporarily isolating fluid flowing between the surface of a wellbore and the formation through a wellbore tubular. Such procedures can include flow control operations, completion operations, and/or interventions. The isolation of the wellbore typically involves the use of a mechanical component being disposed in the flow path to provide a seal. Any additional components disposed within the flow path may interfere with the ability of the mechanical components to form a seal, thereby preventing the isolation of the wellbore as needed.

SUMMARY

In an embodiment, a work string for downhole use in a well comprises a safety valve comprising a sealable flow path; a first electrical connection disposed above the safety valve; a second electrical connection disposed below the safety valve; and a jumper electrically coupling the first electrical connection and the second electrical connection, wherein the jumper does not pass through the sealable flow path of the safety valve. The work string may also include an electric submersible pump electrically coupled to the second electrical connection. The work string may also include a pump landing disposed below the second electrical connection, wherein the electric submersible pump may engage the pump landing. The first electrical connection may be electrically coupled to a power source above the first electrical connection. The first electrical connection may comprise a first landing nipple, and the first landing nipple may comprise a first landing shoulder and a first latching indicator. The work string may also include a first latching mechanism that is electrically coupled to a surface of the well. The first latching mechanism may engage the first landing shoulder and the first latching indicator of the first landing nipple, and the first latching mechanism may be electrically coupled to the first electrical connection when the first latching mechanism engages the first landing shoulder. The second electrical connection may comprise a second landing nipple, and the second landing nipple may comprise a second landing shoulder and a second latching indicator. The work string may also include a second latching mechanism that is electrically coupled to an electric submersible pump. The second latching mechanism may engage the second landing shoulder and the second latching indicator of the second landing nipple, and the second latching mechanism may be electrically coupled to the second electrical connection when the second latching mechanism engages the second landing shoulder. The safety valve may comprise a sealing element configured to substantially seal the sealable flow path in a closed configuration and allow flow through the sealable flow path in an open configuration. The sealing element may comprise a flapper for engaging a corresponding flapper seal, a ball for engaging a ball valve seat, a gate for engaging a gate valve seat, or a sleeve slidingly disposed within a window.

In an embodiment, a method comprises electrically coupling a first electrical connection with a second electrical connection in a work string disposed within a well and providing an electrical current to the first electrical connection. The work string comprises a safety valve; the first electrical connection disposed above the safety valve; the second electrical connection disposed below the safety valve; and a jumper electrically coupling the first electrical connection and the second electrical connection, wherein the jumper does not pass through a sealable flow path of the safety valve, and wherein the second electrical connection is electrically coupled to a subsurface electric component. The subsurface electric component may comprise an electric submersible pump. The work string may also include a landing disposed below the second electrical connection, and the method may also include engaging the subsurface electric component in the landing. The first electrical connection may comprise a first landing nipple, and the method may also include engaging a first latching mechanism with the first landing nipple, where the first latching mechanism is electrically coupled to a surface of the well. Engaging the first latching mechanism with the first landing nipple may comprise activating the first latching mechanism using a weight, an impact, a hydraulic mechanism, a longitudinal motion, a rotational motion, or any combination thereof. The second electrical connection may comprise a second landing nipple, and the method may also include engaging a second latching mechanism with the second landing nipple, where the second latching mechanism is electrically coupled to the subsurface electric component. Engaging the second latching mechanism with the second landing nipple may comprise activating the second latching mechanism using a weight, an impact, a hydraulic mechanism, a longitudinal motion, a rotational motion, or any combination thereof.

In an embodiment, a method comprises producing a hydrocarbon from wellbore comprising a work string and isolating a first portion of the wellbore above the safety valve from a second portion of the wellbore below the safety valve using a sealable flow path. The work string comprises: a safety valve comprising the sealable flow path; a first electrical connection disposed above the safety valve, where the first electrical connection is electrically coupled to a power source; a second electrical connection disposed below the safety valve, where the second electrical connection is electrically coupled to an electric pump; and a jumper electrically coupling the first electrical connection and the second electrical connection, where the jumper does not pass through the sealable flow path of the safety valve.

These and other features will be more clearly understood from the following detailed description taken in conjunction with the accompanying drawings and claims.

BRIEF DESCRIPTION OF THE DRAWINGS

For a more complete understanding of the present disclosure and the advantages thereof, reference is now made to the following brief description, taken in connection with the accompanying drawings and detailed description:

FIG. 1 is a schematic view of an embodiment of a subterranean formation and wellbore operating environment.

FIG. 2 is a schematic cross-section of a work string according to an embodiment.

FIG. 3 is a schematic cross-section of a work string according to an embodiment.

FIG. 4 is a schematic cross-section of a work string according to an embodiment.

DETAILED DESCRIPTION OF THE EMBODIMENTS

In the drawings and description that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. The drawing figures are not necessarily to scale. Certain features of the invention may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in the interest of clarity and conciseness. Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is to be considered an exemplification of the principles of the invention, and is not intended to limit the invention to that illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed infra may be employed separately or in any suitable combination to produce desired results.

Unless otherwise specified, any use of any form of the terms “connect,” “engage,” “couple,” “attach,” or any other term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described. In the following discussion and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to . . . ”. Reference to up or down will be made for purposes of description with “up,” “upper,” “upward,” or “upstream” meaning toward the surface of the wellbore and with “down,” “lower,” “downward,” or “downstream” meaning toward the terminal end of the well, regardless of the wellbore orientation. The term “zone” or “pay zone” as used herein refers to separate parts of the wellbore designated for treatment or production and may refer to an entire hydrocarbon formation or separate portions of a single formation such as horizontally and/or vertically spaced portions of the same formation. The various characteristics mentioned above, as well as other features and characteristics described in more detail below, will be readily apparent to those skilled in the art with the aid of this disclosure upon reading the following detailed description of the embodiments, and by referring to the accompanying drawings.

A safety valve system may be employed within a well or a wellbore tubular string to enable the flow of fluids from within the wellbore to be isolated during use. Various electrical components can be used within wellbores that require an electrical connection in order to function. When the electrical connection passes through a safety valve, the sealable path may be blocked, thereby preventing the safety valve from forming a seal and isolating the flow of fluids within the well. The work string described herein allows a safety valve function to be maintained even while using a cable deployed downhole tool such as an electrical component deployed below the safety valve.

Turning to FIG. 1, an example of a wellbore operating environment is shown. As depicted, the operating environment comprises a drilling rig 107 that is positioned on the earth's surface 105 and extends over and around a wellbore 115 that penetrates a subterranean formation 103 for the purpose of recovering hydrocarbons. The wellbore 115 may be drilled into the subterranean formation 103 using any suitable drilling technique. The wellbore 115 extends substantially vertically away from the earth's surface 105 over a vertical wellbore portion 117, deviates from vertical relative to the earth's surface 105 over a deviated wellbore portion 137, and transitions to a horizontal wellbore portion 119. In alternative operating environments, all or portions of a wellbore may be vertical, deviated at any suitable angle, horizontal, and/or curved. The wellbore may be a new wellbore, an existing wellbore, a straight wellbore, an extended reach wellbore, a sidetracked wellbore, a multi-lateral wellbore, and other types of wellbores for drilling and completing one or more production zones. Further the wellbore may be used for both producing wells and injection wells. In an embodiment, the wellbore may be used for purposes other than or in addition to hydrocarbon production, such as uses related to geothermal energy and/or the production of water (e.g., potable water).

A wellbore tubular string 121 including a work string comprising the safety valve as described herein may be lowered into the subterranean formation 103 for a variety of drilling, completion, production, workover, and/or treatment procedures throughout the life of the wellbore. The embodiment shown in FIG. 1 illustrates the wellbore tubular 121 in the form of a completion and/or work string being lowered into the subterranean formation. It should be understood that the wellbore tubular 121 is equally applicable to any type of wellbore tubular being inserted into a wellbore, including as non-limiting examples drill pipe, production tubing, rod strings, and coiled tubing. In the embodiment shown in FIG. 1, the wellbore tubular 121 comprising the safety valve may be conveyed into the subterranean formation 103 in a conventional manner.

As described in more detail herein, the safety valve system for use in the wellbore 115 may comprise a safety valve 102 comprising a sealable flow path 104, a first electrical connection 106 disposed above the safety valve 102, a second electrical connection 108 disposed below the safety valve 102, and a jumper 110 electrically coupling the first electrical connection 106 and the second electrical connection 108, where the jumper 110 does not pass through the sealable flow path 104 of the safety valve 102.

The drilling rig 107 comprises a derrick 109 with a rig floor 111 through which the wellbore tubular 121 extends downward from the drilling rig 107 into the wellbore 115. The drilling rig 107 comprises a motor driven winch and other associated equipment for extending the wellbore tubular 121 into the wellbore 115 to position the wellbore tubular 121 at a selected depth. While the operating environment depicted in FIG. 1 refers to a stationary drilling rig 107 for lowering and setting the wellbore tubular 121 comprising the running tool within a land-based wellbore 115, in alternative embodiments, mobile workover rigs, wellbore servicing units (such as coiled tubing units), and the like may be used to lower the wellbore tubular 121 comprising the running tool into a wellbore. It should be understood that a wellbore tubular 121 comprising the running tool may alternatively be used in other operational environments, such as within an offshore wellbore operational environment. In alternative operating environments, a vertical, deviated, or horizontal wellbore portion may be cased and cemented and/or portions of the wellbore may be uncased.

Regardless of the type of operational environment in which the safety valve is used, it will be appreciated that the safety valve allows for the use of an electrical component (e.g., a cable deployed electric submersible pump (ESP)) while continuing to allow for the proper operation of a downhole safety valve (e.g., a Tubing Retrievable Safety Valve (TRSV)). In an embodiment, the safety valve function is maintained through the safety valve 102 since an electrical connection does not need to pass through the sealable flow path 104 of the safety valve 102.

As shown in the embodiment schematically illustrated in FIG. 2, the first electrical connection 106 may be part of a first landing nipple 120, and the second electrical connection 108 may be part of a second landing nipple 122. The first landing nipple 120 may comprise a first landing shoulder 112 and a first latching indicator 114, and the second landing nipple 122 may comprise a second landing shoulder 116 and a second latching indicator 118.

The safety valve 102 may be disposed between the first landing nipple 120 and the second landing nipple 122, and the safety valve 102 may comprise a sealing element (e.g., flapper 124) generally located in a sealable flow path 104 that may include those known in the art for providing fluid isolation within a wellbore. In an embodiment, the sealing element is configured to substantially seal the sealable flow path in a closed configuration and allow flow through the sealable flow path in an open configuration. Such safety valves may be automatically activating or controlled through the use of a control line using, for example, fluid pressure or an electrical signal to actuate the safety valve 102. The sealing element may comprise a flapper 124 for engaging a corresponding flapper seal. In alternative embodiments, the sealing element may comprise a ball for engaging a ball valve seat, a gate for engaging a gate valve seat, a sleeve slidingly disposed within a window, combinations thereof, and any additional sealing mechanism known to one of ordinary skill in the art. In an embodiment, the safety valve 102 may be a tubing retrievable safety valve or a cable retrievable safety valve.

In an embodiment, the safety valve 102 comprises a flapper-type safety valve as illustrated in FIGS. 2-4. A flapper-type safety valve generally comprises a tubular body member with a longitudinal bore (e.g., sealable flow path 104) that extends therethrough. An actuator, usually referred to as a flow tube, may be disposed within the body member and is configured to longitudinally translate between the open position of the safety valve 102 and the closed position of the safety valve 102 within the body member. A biasing member such as a spring may be disposed about the actuator to act upon the actuator, thereby biasing the actuator away from a sealing element, which is usually referred to as a flapper 124. The sealing element is pivotably mounted via a hinge (typically with a hinge spring to bias the sealing element into the flow path to provide a closed position) within the body member to control fluid flow through the longitudinal bore. In an embodiment, a rod-piston system, or other hydraulic operating piston, such as an annular piston may be provided to controllably translate the actuator within the longitudinal bore, and to actuate the sealing element between an open position and a closed position and/or a closed position and an open position. The safety valve 102 may generally comprise a control line inlet that can be connected to a control line and provide a control fluid to the piston. Once connected, the control line is configured to be in fluid communication with a piston disposed within a piston rod chamber. A first end of the piston may be in contact with hydraulic fluid provided thereto through the control line. A second end of the piston is operatively connected, in any suitable manner, to the actuator. When the pressure of hydraulic fluid in the control line exceeds the force needed to compress the biasing member (e.g., spring), the piston is forced downwardly, thereby causing the actuator (e.g., the flow tube) to come into contact with, and open, the sealing element. In the event that the hydraulic pressure applied to the piston is decreased, the biasing member forces the actuator upwardly away from the closure member. The closure member is then rotated, and biased, into a closed position by action of a hinge spring to a normally closed position to prevent fluid flow into the actuator and through the longitudinal bore.

In an embodiment, the safety valve 102 may comprise a ball valve. A ball valve generally comprises a variety of components to provide a seal (e.g., a ball/seat interface) and actuate a ball disposed within a body of the valve. A ball valve assembly may comprise cylindrical retaining members disposed on opposite sides of the ball. One or more seats or seating surfaces may be disposed above and/or below the ball to provide a fluid seal with the ball. The ball generally comprises a truncated sphere having planar surfaces on opposite sides of the sphere. Planar surfaces may each have a spigot comprising a projection (e.g., cylindrical projections) extending outwardly therefrom, and a radial groove extending from the spigots to the edge of the planar surface. An actuation member having two parallel arms may be positioned about the ball and the retaining members. The spigots may be received in windows through each of the arms. Actuation pins may be provided on each of the inner sides of the arms, and the pins may be received within the grooves on the ball. In the open position, the ball is positioned so as to allow the flow of fluid through the ball valve by allowing fluid to flow through an interior fluid passageway (e.g., a bore or hole) extending through the ball. The interior flow passage may have its longitudinal axis disposed at about 90 degrees to the longitudinal axis when the ball is in the closed position, and the interior flow passage may have its longitudinal axis substantially aligned with the longitudinal axis when the ball is in the open position The ball may be rotated by linear movement of the actuation member along the longitudinal axis. The pins move as the actuation member moves, causing the ball to rotate due to the positioning of the pins within the grooves on the ball. During operation, the ball is actuated from an open position to a closed position by rotating the ball such that the interior flow passage is rotated out of alignment with the flow of fluid, thereby forming a fluid seal with one or more seats or seating surfaces and closing the valve. Similarly, the ball is actuated from a closed position to an open position by rotating the ball such that the interior flow passage is rotated into alignment with the flow of fluid.

The first electrical connection 106, the second connection 108, and the jumper 110 may comprise one or more electrical connection pathways. For example, various metallic structures within the wellbore such as the casing, the tubing, and the like may provide a conduction path, thereby allowing for the electrical connections to comprise a single electrical conductor and provide a single electrical connection pathway. In some embodiments, a plurality of conduction pathways may be contained within the electrical connections, allowing for a plurality of electrical connection pathways. For example, a wireline with a plurality of conductors may be contained in the cable and/or the jumper 110, and the first electrical connection 106 and/or the second electrical connection 108 may be configured to provide a corresponding number of electrical pathways.

In an embodiment, the first electrical connection 106 may be electrically coupled to a power source above the first electrical connection 106, for example at the surface of the well. As shown in FIGS. 3 and 4, a first latching mechanism 302 may be used to couple a connector 304 (e.g., a cable) to the first electrical connection 106. The first latching mechanism 302 may engage the first landing shoulder 112 and the first latching indicator 114 of the first landing nipple 120. The first latching mechanism 302 may be electrically coupled to the first electrical connection 106 when the first latching mechanism is engaged with the first landing shoulder 112. The work string may also include a second latching mechanism 306 that is electrically coupled to an electric component 308 such as an electric submersible pump. In this embodiment, the second latching mechanism 306 may engage the second landing shoulder 116 and the second latching indicator 118 of the second landing nipple 122. Further, the second latching mechanism 306 may be electrically coupled to the second electrical connection 108 when the second latching mechanism 306 is engaged with the second landing shoulder 116.

The work string may also include a pump landing 310 disposed below the second electrical connection 108, and the electric component 308 (e.g., an ESP) may engage the pump landing 310. A cable 312 may electrically couple the second latching mechanism 306 and the electric component 308. The work string may also include an electric submersible pump electrically coupled to the second electrical connection 108.

In an embodiment, the first latching mechanism 302 may be ported (e.g., comprise one or more ports 314) to provide fluid communication through the first latching mechanism 302 and the first landing nipple 120 and past the first latching mechanism 302. The second latching mechanism 306 may be ported (e.g., comprise one or more ports 316) to provide fluid communication through the second latching mechanism 306 and the second landing nipple 122 and past the second latching mechanism 306.

As shown in FIGS. 2 to 4, a method of using the work string comprises electrically coupling a subsurface electric component 308 with a second electrical connection 108 in a work string disposed within a well, and providing an electrical current to a first electrical connection 106 coupled to the second electrical connection 108. The work string may comprise a safety valve 102, a first electrical connection 106 disposed above the safety valve 102, the second electrical connection 108 disposed below the safety valve 102, and a jumper 110 electrically coupling the first electrical connection 106 and the second electrical connection 108, where the jumper 110 does not pass through a sealable flow path 104 of the safety valve 102. In an embodiment, the subsurface electric component 308 may comprise an electric submersible pump.

As shown in FIG. 3, the electric component 308 may be coupled to the second electrical connection 108 using a second latching mechanism 306 disposed on a suitable conveyance device. Suitable conveyance devices may include, but are not limited to, a slickline, wireline, an electrical connector, or coiled tubing. In order to couple the second electrical connection 108 to the second latching mechanism 306, the safety valve 102 is actuated to the open position to allow the electrical component 308, connector 312, and second latching mechanism 306 to pass through the safety valve 102. The second latching mechanism 306 may be configured to engage and electrically couple to the second electrical connection 108. In an embodiment, the second latching mechanism 306 may be activated so that the second latching mechanism 306 engages the second landing shoulder 116, and a biased button 318 on the second latching mechanism 306 engages the second latching indicator 118 to secure the second latching mechanism 306 in place. The second latching mechanism 306 may be engaged with the second landing nipple 122 by activating the latching mechanism using weight, impact, a hydraulic mechanism, longitudinal motion, rotational motion, or any combination thereof. For example, a pressure signal may be supplied to the second landing nipple 122 and used to actuate a hydraulic mechanism (e.g., a piston) forming part of the second latching mechanism 306, and/or a hydraulic mechanism forming part of the second landing nipple 122.

In an embodiment, the second electrical connection 108 may be formed as part of the second latch indicator 118 on the second landing nipple 122. In this embodiment, an electrical connection may be formed when the biased button 318 engages and/or contacts a counterpart contact plate in the second latch indicator 118. The presence of an electrical signal (for example, detectable at the surface) may indicate the successful landing/engagement of the second latch mechanism 306 with the second landing nipple 122.

As shown in FIG. 4, an electrical connection may then be established with the first electrical connection 106 using a connector 304 and the first latching mechanism 302 coupled to a power source. In an embodiment, the power source may include an electrical source at the surface of the wellbore, and/or a downhole power source such as a downhole generator and/or battery pack. The first latching mechanism 302 may be disposed on a suitable conveyance device. Suitable conveyance devices may include, but are not limited to, a slickline, wireline, an electrical connector, or a coiled tubing. In an embodiment, the connector 304 may comprise the conveyance device. The first latching mechanism 302 may be configured to engage and electrically couple to the first electrical connection 106. The first latching mechanism 302 may be activated so that the first latching mechanism 302 engages the first landing shoulder 112, and a biased button 320 on the first latching mechanism 302 engages the first latching indicator 114 to secure the first latching mechanism 302 in place. The first latching mechanism 302 may be engaged with the first landing nipple 120 using a latching mechanism that uses weight, impact, a hydraulic mechanism, longitudinal motion, rotational motion, or any combination thereof. For example, a pressure signal may be supplied to the first landing nipple 120 and used to actuate a hydraulic mechanism (e.g., a piston) forming part of the second latching mechanism 306, and/or a hydraulic mechanism forming part of the first landing nipple 120.

In an embodiment, the first electrical connection 106 may be formed as part of the first latch indicator 114 on the first landing nipple 120. In this embodiment, an electrical connection may be formed when the biased button 320 engages and/or contacts a counterpart contact plate in the first latch indicator 114. The presence of an electrical signal (for example, detectable at the surface) may indicate the successful landing/engagement of the first latch mechanism 302 with the first landing nipple 120.

The first latching mechanism 302, the second latching mechanism 306, the first landing nipple 120, and/or the second landing nipple 122 may be ported or otherwise configured (e.g., with flow paths, fluid channels/grooves, or the like) to allow fluid to flow through the first latching mechanism 302, the second latching mechanism 306, the first landing nipple 120, and/or the second landing nipple 122 to the surface of the wellbore during production. Since no cable or connector is disposed within the sealable flow path 104 of the safety valve 102, the safety valve 102 may be operated at any point during the production of the wellbore to isolate a first portion of the wellbore above the safety valve 102 from a second portion of the wellbore below the safety valve 102 using the sealable flow path 104.

While the method of connecting the electric component within the work string is described as taking place in a plurality of steps and trips into the well, the electrical coupling of electric component with the second electrical connection and providing the electrical current to the first electrical connection may be performed in a single trip into the well. A method of operating a wellbore may comprise producing a hydrocarbon from the wellbore comprising a work string, and isolating a first portion of the wellbore above the safety valve from a second portion of the wellbore below the safety valve using the sealable flow path. Producing the hydrocarbon from the wellbore may include, for example, supplying electrical current to the electric component (e.g., an electric submersible pump) via the electrical connections described herein, where the electric component pumps the hydrocarbon to the surface via the sealable flow path 104. The work string may comprise a safety valve, a first electrical connection disposed above the safety valve, wherein the first electrical connection is electrically coupled to a power source, a second electrical connection disposed below the safety valve, wherein the second electrical connection is electrically coupled to an electric submersible pump, and a jumper electrically coupling the first electrical connection and the second electrical connection, wherein the jumper does not pass through a sealable flow path of the safety valve.

Having described the systems and methods, various embodiments may include, but are not limited to:

1. In an embodiment, a work string for downhole use in a well comprises a safety valve comprising a sealable flow path; a first electrical connection disposed above the safety valve; a second electrical connection disposed below the safety valve; and a jumper electrically coupling the first electrical connection and the second electrical connection, where the jumper does not pass through the sealable flow path of the safety valve.

2. The work string of embodiment 1, further comprising: an electric submersible pump electrically coupled to the second electrical connection.

3. The work string of embodiment of embodiment 2, further comprising a pump landing disposed below the second electrical connection, wherein the electric submersible pump engages the pump landing.

4. The work string of embodiment 1 or 2, wherein the first electrical connection is electrically coupled to a power source above the first electrical connection.

5. The work string of any of embodiments 1 to 3, wherein the first electrical connection comprises a first landing nipple.

6. The work string of embodiment 5, wherein the first landing nipple comprises a first landing shoulder and a first latching indicator.

7. The work string of embodiment 6, further comprising a first latching mechanism that is electrically coupled to a surface of the well.

8. The work string of 7, wherein the first latching mechanism engages the first landing shoulder and the first latching indicator of the first landing nipple.

9. The work string of embodiment 7 or 8, wherein the first latching mechanism is electrically coupled to the first electrical connection when the first latching mechanism engages the first landing shoulder.

10. The work string of any of embodiments 5 to 9, wherein the first landing nipple is ported to provide fluid communication through the first landing nipple.

11. The work string of any of embodiments 1 to 4, wherein the second electrical connection comprises a second landing nipple.

12. The work string of embodiment 11, wherein the second landing nipple comprises a second landing shoulder and a second latching indicator.

13. The work string of embodiment 12, further comprising a second latching mechanism that is electrically coupled to an electric submersible pump.

14. The work string of embodiment 13, wherein the second latching mechanism engages the second landing shoulder and the second latching indicator of the second landing nipple.

15. The work string of embodiment 13 or 14, wherein the second latching mechanism is electrically coupled to the second electrical connection when the second latching mechanism engages the second landing shoulder.

16. The work string of any of embodiments 11 to 15, wherein the second landing nipple is ported to provide fluid communication through the second landing nipple.

17. The work string of any of embodiments 1 to 16, wherein the safety valve comprises a sealing element.

18. The work string of embodiment 17, wherein the sealing element comprises a flapper for engaging a corresponding flapper seal, a ball for engaging a ball valve seat, a gate for engaging a gate valve seat, or a sleeve slidingly disposed within a window.

19. The work string of any of embodiments 1 to 18, wherein the first electrical connection, the second connection, and the jumper comprise a plurality of electrical connection pathways.

20. The work string of any of embodiments 1 to 19, wherein the safety valve is a tubing retrievable safety valve.

21. The work string of any of embodiments 1 to 20, wherein the safety valve is a cable retrievable safety valve.

22. In an embodiment, a method comprises electrically coupling a subsurface electric component with a second electrical connection in a work string disposed within a well, wherein the work string comprises: a safety valve; a first electrical connection disposed above the safety valve; the second electrical connection disposed below the safety valve; and a jumper electrically coupling the first electrical connection and the second electrical connection, wherein the jumper does not pass through a sealable flow path of the safety valve; and providing an electrical current to the first electrical connection.

23. The method of embodiment 22, wherein the subsurface electric component comprises an electric submersible pump.

24. The method of embodiment 22 or 23, wherein the work string further comprises a landing disposed below the second electrical connection, and further comprising engaging the subsurface electric component in the landing.

25. The method of any of embodiments 22 to 24, wherein providing the electrical current to the first electrical connection comprises electrically coupling a power source at a surface of the well to the first electrical connection.

26. The method of any of embodiments 22 to 25, wherein the first electrical connection comprises a first landing nipple.

27. The method of embodiment 26, wherein the first landing nipple comprises a first landing shoulder and a first latching indicator.

28. The method of embodiment 27, further comprising engaging a first latching mechanism with the first landing nipple, wherein the first latching mechanism is electrically coupled to a surface of the well.

29. The method of embodiment 28, wherein the first latching mechanism engages the first landing shoulder and the first latching indicator of the first landing nipple.

30. The method of embodiment 29, wherein the first latching mechanism electrically couples to the first electrical connection when the first latching mechanism engages the first landing shoulder.

31. The method of embodiment 30, wherein engaging the first latching mechanism with the first landing nipple comprises activating a latching mechanism that uses weight, impact, a hydraulic mechanism, longitudinal motion, rotational motion, or any combination thereof.

32. The method of any of embodiments 26 to 31, wherein the first landing nipple is ported to provide fluid communication through the first landing nipple.

33. The method of any of embodiments 22 to 32, wherein the second electrical connection comprises a second landing nipple.

34. The method of embodiment 33, wherein the second landing nipple comprises a second landing shoulder and a second latching indicator.

35. The method of embodiment 34, further comprising engaging a second latching mechanism with the second landing nipple, wherein the second latching mechanism is electrically coupled to the subsurface electric component.

36. The method of embodiment 35, wherein the second latching mechanism engages the second landing shoulder and the second latching indicator of the second landing nipple.

37. The method of embodiment 36, wherein the second latching mechanism electrically couples to the second electrical connection when the second latching mechanism engages the second landing shoulder.

38. The method of embodiment 37, wherein engaging the second latching mechanism with the second landing nipple comprises activating a latching mechanism that uses weight, impact, a hydraulic mechanism, longitudinal motion, rotational motion, or any combination thereof.

39. The method of any of embodiments 33 to 38, wherein the second landing nipple is ported to provide fluid communication through the second landing nipple.

40. The method of any of embodiments 22 to 39, wherein the safety valve comprises a sealing element.

41. The method of embodiment 40, wherein the sealing element comprises a flapper for engaging a corresponding flapper seal, a ball for engaging a ball valve seat, a gate for engaging a gate valve seat, or a sleeve slidingly disposed within a window.

42. The method of any of embodiments 22 to 41, wherein the first electrical connection, the second connection, and the jumper comprise a plurality of electrical connection pathways.

43. The method of any of embodiments 22 to 42, wherein the safety valve is a tubing retrievable safety valve.

44. The method of any of embodiments 22 to 43, wherein the safety valve is a cable retrievable safety valve.

45. The method of any of embodiments 22 to 44, wherein electrically coupling the subsurface electric component with the second electrical connection and providing the electrical current to the first electrical connection is performed in a single trip into the well.

46. The method of any of embodiments 22 to 45, wherein electrically coupling the subsurface electric component with the second electrical connection and providing the electrical current to the first electrical connection is performed in a plurality of trips into the well.

47. The method of any of embodiments 22 to 46, wherein electrically coupling the subsurface electric component with the second electrical connection comprises the use of a slickline, wireline, an electrical connector, or a coiled tubing.

48. The method of any of embodiments 22 to 47, wherein providing the electrical current to the first electrical connection comprises the use of a slickline, wireline, an electrical connector, or a coiled tubing.

49. In an embodiment, a method comprises producing a hydrocarbon from wellbore comprising a work string, wherein the work string comprises: a safety valve; a first electrical connection disposed above the safety valve, wherein the first electrical connection is electrically coupled to a power source; a second electrical connection disposed below the safety valve, wherein the second electrical connection is electrically coupled to an electric pump; and a jumper electrically coupling the first electrical connection and the second electrical connection, wherein the jumper does not pass through a sealable flow path of the safety valve; and isolating a first portion of the wellbore above the safety valve from a second portion of the wellbore below the safety valve using the sealable flow path.

At least one embodiment is disclosed and variations, combinations, and/or modifications of the embodiment(s) and/or features of the embodiment(s) made by a person having ordinary skill in the art are within the scope of the disclosure. Alternative embodiments that result from combining, integrating, and/or omitting features of the embodiment(s) are also within the scope of the disclosure. Where numerical ranges or limitations are expressly stated, such express ranges or limitations should be understood to include iterative ranges or limitations of like magnitude falling within the expressly stated ranges or limitations (e.g., from about 1 to about 10 includes, 2, 3, 4, etc.; greater than 0.10 includes 0.11, 0.12, 0.13, etc.). For example, whenever a numerical range with a lower limit, R_(l), and an upper limit, R_(u), is disclosed, any number falling within the range is specifically disclosed. In particular, the following numbers within the range are specifically disclosed: R=R_(l)+k*(R_(u)−R_(l)), wherein k is a variable ranging from 1 percent to 100 percent with a 1 percent increment, i.e., k is 1 percent, 2 percent, 3 percent, 4 percent, 5 percent, . . . 50 percent, 51 percent, 52 percent, . . . , 95 percent, 96 percent, 97 percent, 98 percent, 99 percent, or 100 percent. Moreover, any numerical range defined by two R numbers as defined in the above is also specifically disclosed. Use of the term “optionally” with respect to any element of a claim means that the element is required, or alternatively, the element is not required, both alternatives being within the scope of the claim. Use of broader terms such as comprises, includes, and having should be understood to provide support for narrower terms such as consisting of, consisting essentially of, and comprised substantially of. Accordingly, the scope of protection is not limited by the description set out above but is defined by the claims that follow, that scope including all equivalents of the subject matter of the claims. Each and every claim is incorporated as further disclosure into the specification and the claims are embodiment(s) of the present invention. 

1. A work string for downhole use in a well comprising: a safety valve comprising a sealable flow path; a first electrical connection disposed above the safety valve, wherein the first electrical connection comprises a first landing nipple; a second electrical connection disposed below the safety valve; and a jumper electrically coupling the first electrical connection and the second electrical connection, wherein the jumper does not pass through the sealable flow path of the safety valve.
 2. The work string of claim 1, further comprising an electric submersible pump electrically coupled to the second electrical connection.
 3. The work string of claim of claim 2, further comprising a pump landing disposed below the second electrical connection, wherein the electric submersible pump engages the pump landing.
 4. The work string of claim 1, wherein the first electrical connection is electrically coupled to a power source above the first electrical connection.
 5. (canceled)
 6. The work string of claim 1, wherein the first landing nipple comprises a first landing shoulder and a first latching indicator.
 7. The work string of claim 6, further comprising a first latching mechanism that is electrically coupled to a surface of the well, wherein the first latching mechanism engages the first landing shoulder and the first latching indicator of the first landing nipple, and wherein the first latching mechanism is electrically coupled to the first electrical connection when the first latching mechanism engages the first landing nipple.
 8. The work string of claim 1, wherein the second electrical connection comprises a second landing nipple.
 9. The work string of claim 8, wherein the second landing nipple comprises a second landing shoulder and a second latching indicator.
 10. The work string of claim 9, further comprising a second latching mechanism that is electrically coupled to an electric submersible pump, wherein the second latching mechanism engages the second landing shoulder and the second latching indicator of the second landing nipple, and wherein the second latching mechanism is electrically coupled to the second electrical connection when the second latching mechanism engages the second landing nipple.
 11. The work string of claim 1, wherein the safety valve comprises a sealing element configured to substantially seal the sealable flow path in a closed configuration and allow flow through the sealable flow path in an open configuration.
 12. The work string of claim 11, wherein the sealing element comprises a flapper for engaging a corresponding flapper seal, a ball for engaging a ball valve seat, a gate for engaging a gate valve seat, or a sleeve slidingly disposed within a window.
 13. A method comprising: electrically coupling a first electrical connection with a second electrical connection in a work string disposed within a well, wherein the work string comprises: a safety valve; the first electrical connection disposed above the safety valve, wherein the first electrical connection comprises a first landing nipple, and wherein the method further comprising engaging a first latching mechanism with the first landing nipple, wherein the first latching mechanism is electrically coupled to a surface of the well; the second electrical connection disposed below the safety valve; and a jumper electrically coupling the first electrical connection and the second electrical connection, wherein the jumper does not pass through a sealable flow path of the safety valve, and wherein the second electrical connection is electrically coupled to a subsurface electric component; and providing an electrical current to the first electrical connection.
 14. The method of claim 13, wherein the subsurface electric component comprises an electric submersible pump.
 15. The method of claim of claim 14, wherein the work string further comprises a landing disposed below the second electrical connection, and wherein the method further comprises engaging the subsurface electric component in the landing.
 16. (canceled)
 17. The method of claim 13, wherein engaging the first latching mechanism with the first landing nipple comprises activating the first latching mechanism using a weight, an impact, a hydraulic mechanism, a longitudinal motion, a rotational motion, or any combination thereof.
 18. The method of claim 13, wherein the second electrical connection comprises a second landing nipple, and wherein the method further comprising engaging a second latching mechanism with the second landing nipple, wherein the second latching mechanism is electrically coupled to the subsurface electric component.
 19. The method of claim 18, wherein engaging the second latching mechanism with the second landing nipple comprises activating the second latching mechanism using a weight, an impact, a hydraulic mechanism, a longitudinal motion, a rotational motion, or any combination thereof.
 20. A method comprising: producing a hydrocarbon from wellbore comprising a work string, wherein the work string comprises: a safety valve comprising a sealable flow path; a first electrical connection disposed above the safety valve, wherein the first electrical connection is electrically coupled to a power source and wherein the first electrical connection comprises a first landing nipple; a second electrical connection disposed below the safety valve, wherein the second electrical connection is electrically coupled to an electric pump; and a jumper electrically coupling the first electrical connection and the second electrical connection, wherein the jumper does not pass through the sealable flow path of the safety valve; and isolating a first portion of the wellbore above the safety valve from a second portion of the wellbore below the safety valve using the sealable flow path. 